GDB Information Disclosure Requirements Information ... · commissioned and asset disposals should...

Commerce Commission Information Disclosure Template

GDB Information Disclosure Requirements

Information Templates

forSchedules 1–10

Company Name Vector - gas distribution business

Disclosure Date 4 December 2014

Disclosure Year (year ended) 30 June 2014

Templates for Schedules 1–10

Template Version 3.0. Prepared 14 April 2014

1 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx CoverSheet


Table of Contents

Schedule Description

1 Analytical Ratios

2 Report on Return on Investment

3 Report on Regulatory Profit

4 Report on Value of the Regulatory Asset Base (Rolled Forward)

5a Report on Regulatory Tax Allowance

5b Report on Related Party Transactions

5c Report on Term Credit Spread Differential Allowance

5d Report on Cost Allocations

5e Report on Asset Allocations

5h Report on Transitional Financial Information

6a Report on Capital Expenditure for the Disclosure Year

6b Report on Operational Expenditure for the Disclosure Year

7 Comparison of Forecasts to Actual Expenditure

8 Report on Billed Quantities and Line Charge Revenues (by Price Component)

9a Asset Register

9b Asset Age Profile

9c Report on Pipeline Data

9d Report on Demand

10a Report on Network Reliability and Interruptions

10b Report on Network Integrity and Consumer Service

2 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx TOC


Disclosure Template Guidelines for Information EntryThese templates have been prepared for use by GDBs when making disclosures under subclauses 2.3.1, 2.4.21, 2.4.22,

2.5.1, and 2.5.2 of the Gas Distribution Information Disclosure Determination 2012. Disclosures must be made

available to the public within 6 months after the end of the disclosure year and a copy provided to the Commission

within 5 working days of being disclosed to the public.

Version 3.0 templatesThese templates correct formula errors contained in previous versions of the templates. A list of the formula

corrections can be found in the ID issues register under "Excel Template Issues - v2.X (2013)" in the category column.

We have included additional guidance for schedules 2, 4 and 5a indicating where information for certain rows are

expected to be sourced from.

Company Name and DatesTo prepare the templates for disclosure, the supplier's company name should be entered in cell C8, the date of the last

day of the current (disclosure) year should be entered in cell C12, and the date on which the information is disclosed

should be entered in cell C10 of the CoverSheet worksheet.

The cell C12 entry (current year) is used to calculate disclosure years in the column headings that show above some of

the tables and in labels adjacent to some entry cells. It is also used to calculate the ‘For year ended’ date in the

template title blocks (the title blocks are the light green shaded areas at the top of each template).

The cell C8 entry (company name) is used in the template title blocks.

Dates should be entered in day/month/year order (Example -"1 April 2013").

Data Entry Cells and Calculated CellsData entered into this workbook may be entered only into the data entry cells. Data entry cells are the bordered,

unshaded areas (white cells) in each template. Under no circumstances should data be entered into the workbook

outside a data entry cell.

In some cases, where the information for disclosure is able to be ascertained from disclosures elsewhere in the

workbook, such information is disclosed in a calculated cell. Under no circumstances should the formulas in a

calculated cell be overwritten.

Validation Settings on Data Entry CellsTo maintain a consistency of format and to help guard against errors in data entry, some data entry cells test keyboard

entries for validity and accept only a limited range of values. For example, entries may be limited to a list of category

names, to values between 0% and 100%, or either a numeric entry or the text entry “N/A”. Where this occurs, a

validation message will appear when data is being entered. These checks are applied to keyboard entries only and not,

for example, to entries made using Excel’s copy and paste facility.

Conditional Formatting Settings on Data Entry CellsSchedule 9b columns Z to AD (2013 to 2017) contain conditional formatting. The data entry cells for future years are

hidden (are changed from white to yellow).

Schedule 9b cells AG10 to AG637 will change colour if the total assets at year end for each asset class does not equal

the corresponding values in column H in Schedule 9a.

Schedule 9c cell P30 will change colour if P30 (overhead circuit length by terrain) does not equal P18 (overhead circuit

length by operating voltage).

Schedule 4 cells Q97:Q103 and Q105 will change colour if the RAB values do not equal the corresponding values in

table 4(ii).

Inserting Additional Rows and ColumnsThe templates for schedules 4, 5b, 5c, 5d, 5e, 5i, 6a, 8, 9c, 9d, 10a and 10b may require additional rows to be inserted

in tables marked 'include additional rows if needed' or similar.

Additional rows in schedules 5c, 6a, 9c and 9d must not be inserted directly above the first row or below the last row

of a table. This is to ensure that entries made in the new row are included in the totals.

Schedules 5d and 5e may require new cost or asset category rows to be inserted in allocation change tables 5d(iii) and

5e(ii). Accordingly, cell protection has been removed from row 71 of each template to allow blocks of rows to be

copied. The four steps to add new cost category rows to table 5d(iii) and table 5e(ii) are: Select Excel rows 62:69 of the

relevant template, copy, select Excel row 71, then insert copied cells.

The template for schedule 8 may require additional columns to be inserted between column M and Q. To avoid

interfering with the title block entries, these should be inserted to the left of column N. If inserting additional columns,

the formulas for standard consumers total, non-standard consumers totals and total for all consumers will need to be

copied into the cells of the added columns. The formulas can be found in the equivalent cells of the existing columns.

3 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx Guidelines


Disclosures by Sub-NetworkSchedules 8, 9a, 9b, 9c, 9d, 10a and 10b must be completed for the network and for each sub-network. A copy of the

schedule worksheet(s) must be made for each subnetwork and named accordingly.

Schedule ReferencesThe references labelled 'sch ref' in the leftmost column of each template are consistent with the row references in the

Gas Distribution ID Determination 2012 (as issued on 1 October 2012). They provide a common reference between the

rows in the determination and the template. Due to page formatting, the row reference sequences contained in the

determination schedules are not necessarily contiguous.

Description of Calculation ReferencesCalculation cell formulas contain links to other cells within the same template or elsewhere in the workbook. Key cell

references are described in a column to the right of each template. These descriptions are provided to assist data

entry. Cell references refer to the row of the template and not the schedule reference.

Worksheet Completion SequenceCalculation cells may show an incorrect value until precedent cell entries have been complated. Data entry may be

assisted by completing the schedules in the following order:

1. Coversheet

2. Schedules 5a–5e

3. Schedules 6a and 6b

4. Schedule 8

5. Schedule 3

6. Schedule 4

7. Schedule 2

8. Schedule 7

9. Schedules 9a–9d

10. Schedules 10a and 10b

Changes to disclosure year 2013Clauses 2.12.1 to 2.12.7 of the Gas Distribution ID Determination 2012 does not apply for disclosure years 2014 and

onwards.

GDBs do not need to complete transitional schedule 5h and this schedule has been excluded from this version of the

templates.

All schedules in this workbook must now be completed in full and publicly disclosed.

Schedule 2: Report on Return on InvestmentThe ROI calculations are performed in this template.

All suppliers must complete tables 2(i) Return on Investment and 2(ii) Information Supporting the ROI.

Only suppliers who meet either of the two thresholds set out in subclause 2.3.3 of the Gas Distribution Information

Disclosure Determination 2012 need to complete table 2(iii) Information Supporting the Monthly ROI. We expect that

most suppliers will generally not meet either threshold. You will need to work out if you met either threshold using

your own tools (e.g. Excel) and do not need to disclosure these calculations. If you met either threshold you will need

to provide a breakdown of five cash flow items on a month by month basis, as well as your opening revenue related

working capital. The definitions for these items are the same as for the rest of the schedules. The values for assets

commissioned and asset disposals should relate to the RAB (not the unallocated RAB).

The Excel worksheet uses several calculated cells beyond the rightmost edge of the template to calculate the monthly

ROIs. The prior year comparison information in the table 2(i) columns labelled CY-1 and CY-2 should be completed by

copying the results from the previous year's disclosure.

Schedule 8: Report on Billed Quantities and Line Charge RevenuesThis template should be completed in respect of each consumer groups or price category code (as applicable) that

applied in the relevant disclosure year. The 'Average number of ICPs in disclosure year' column entries should be the

arithmetic mean of monthly total ICPs (at month end).

4 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx Guidelines


Company Name

For Year Ended

SCHEDULE 1: ANALYTICAL RATIOS

sch ref

7 1(i): Expenditure Metrics

8

Expenditure per TJ

energy delivered

to ICPs ($/TJ)

Expenditure per

average no. of ICPs

($/ICP)

Ratio of

expenditure to

maximum monthly

amount of gas

entering network

($ per GJ/month)

Expenditure per

km of pipeline for

supply ($/km)

9 Operational expenditure 757 104 8 1,550

10 Network 346 47 3 707

11 Non-network 412 57 4 843

12

13 Expenditure on assets 1,496 205 15 3,061

14 Network 1,436 197 15 2,939

15 Non-network 60 8 1 122

16

17

18 1(ii): Revenue Metrics

19

Revenue per TJ

energy delivered

to ICPs ($/TJ)

Revenue per

average no. of ICPs

($/ICP)

20 Total line charge revenue 3,434 472

21 Standard consumer line charge revenue 6,494 429

22 Non-standard consumer line charge revenue 600 73,609

23

24 1(iii): Service Intensity Measures25

26 Demand density 202

27 Volume density 2 Total TJ delivered to ICPs/Total pipeline length

28 Connection point density 15 Average number of ICPs in disclosure year/Total pipeline length

29 Energy intensity 137 Total GJ delivered to ICPs/Average number of ICPs in disclosure year

30

31 1(iv): Composition of Revenue Requirement

32 ($000) % of revenue

33 Operational expenditure 16,466 21.86%

34 Pass-through and recoverable costs 2,417 3.21%

35 Total depreciation 14,483 19.23%

36 Total revaluation 7,548 10.02%

37 Regulatory tax allowance 10,123 13.44%

38 Regulatory profit/loss 39,277 52.15%

39 Total regulatory income 75,313

40

41 1(v): Reliability

Interruptions per

100km of pipeline

length

42 Interruption rate 19.53

This schedule calculates expenditure, revenue and service ratios from the information disclosed. The disclosed ratios may vary for reasons that are company specific and, as a result, must

be interpreted with care. The Commerce Commission will publish a summary and analysis of information disclosed in accordance with the ID determination. This will include information

disclosed in accordance with this and other schedules, and information disclosed under the other requirements of the determination.

Maximum monthly amount of gas entering network (GJ/month)/Total pipeline length

Vector - gas distribution business

30 June 2014

5 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S1.Analytical Ratios


Company Name

For Year Ended

SCHEDULE 2: REPORT ON RETURN ON INVESTMENT

sch ref

7 2(i): Return on Investment CY-2 CY-1 Current Year CY

8 for year ended 30 Jun 12 30 Jun 13 30 Jun 14

9 Post tax WACC % % %

10 ROI—comparable to a post tax WACC 7.93% 8.24% 7.52%

11

12 Mid-point estimate of post tax WACC 6.89% 6.02% 6.16%

13 25th percentile estimate 6.08% 5.21% 5.35%


15

16

17 Vanilla WACC

18 ROI—comparable to a vanilla WACC 8.72% 8.94% 8.20%

19

20 Mid-point estimate of vanilla WACC 7.69% 6.72% 6.84%



23

24

25 2(ii): Information Supporting the ROI ($000)

26

27 Total opening RAB value 467,458

28 plus Opening deferred tax (19,014)

29 Opening RIV 448,444

30

31 Operating surplus / (deficit) 56,430

32 less Regulatory tax allowance 10,123

33 less Assets commissioned 23,068

34 plus Asset disposals 50

35 Notional net cash flows 23,290

36

37 Total closing RAB value 483,573

38 less Adjustment resulting from asset allocation 32

39 less Lost and found assets adjustment -

40 plus Closing deferred tax (22,545)

41 Closing RIV 460,996

42

43 ROI—comparable to a vanilla WACC 8.20%

44

45 Leverage (%) 44%

46 Cost of debt assumption (%) 5.49%

47 Corporate tax rate (%) 28%

48

49 ROI—comparable to a post tax WACC 7.52%

This schedule requires information on the Return on Investment (ROI) for the GDB relative to the Commerce Commission's estimates of post tax WACC and vanilla WACC. GDBs must

calculate their ROI based on a monthly basis if required by clause 2.3.3 of the ID Determination or if they elect to. If a GDB makes this election, information supporting this calculation

must be provided in 2(iii). GDBs must provide explanatory comment on their ROI in Schedule 14 (Mandatory Explanatory Notes).

This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8.


30 June 2014

6 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S2.Return on Investment


Company Name

For Year Ended

SCHEDULE 2: REPORT ON RETURN ON INVESTMENT

sch ref

This schedule requires information on the Return on Investment (ROI) for the GDB relative to the Commerce Commission's estimates of post tax WACC and vanilla WACC. GDBs must

calculate their ROI based on a monthly basis if required by clause 2.3.3 of the ID Determination or if they elect to. If a GDB makes this election, information supporting this calculation

must be provided in 2(iii). GDBs must provide explanatory comment on their ROI in Schedule 14 (Mandatory Explanatory Notes).



30 June 2014

57 2(iii): Information Supporting the Monthly ROI58

59 Cash flows

60

Total regulatory

income Expenses Tax payments

Assets

commissioned Asset disposals

Notional net cash

flows

61 Month 1 10,357 1,638 916 8 7,811

62 Month 2 10,024 1,460 1,210 5 7,359

63 Month 3 8,368 1,600 1,262 1 5,507

64 Month 4 5,603 1,512 2,426 1 1,666

65 Month 5 4,873 1,524 1,013 2,424 1 (87)

66 Month 6 4,297 1,397 1,643 2 1,259

67 Month 7 4,504 1,550 1,610 5 1,349

68 Month 8 3,995 1,524 1,019 2 1,454

69 Month 9 4,785 1,622 9,110 2,954 4 (8,897)

70 Month 10 4,818 1,512 2,232 18 1,092

71 Month 11 6,300 1,715 1,710 2 2,877

72 Month 12 7,389 1,829 3,662 1 1,899

73 Total 75,313 18,883 10,123 23,068 50 23,289

74

75

76

Opening / closing

RAB

Adjustment

resulting from

asset allocation

Lost and found

assets adjustment

Opening / closing

deferred tax

Revenue related

working capital Total

77 Monthly ROI - opening RIV 467,458 (19,014) 9,615 458,059

78

79 Monthly ROI - closing RIV 483,573 32 - (22,545) 7,389 468,385

80 Monthly ROI - closing RIV less term credit spread differential allowance 468,290

81 Monthly ROI—comparable to a vanilla WACC 7.62%

82

83 Monthly ROI—comparable to a post-tax WACC 6.95%

84

85 2(iv): Year-End ROI Rates for Comparison Purposes86

87 Year-end ROI—comparable to a vanilla WACC 8.54%

88

89 Year-end ROI—comparable to a post-tax WACC 7.86%

90

91 * these year-end ROI values are comparable to the ROI reported in pre 2012 disclosures by GDBs and do not represent the Commission's current view on ROI.

($000)

7 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S2.Return on Investment


Company Name

For Year Ended

SCHEDULE 3: REPORT ON REGULATORY PROFIT

sch ref

7 3(i): Regulatory Profit ($000)

8 Income

9 Line charge revenue 74,664

10 plus Gains / (losses) on asset disposals (50)

11 plus Other regulated income (other than gains / (losses) on asset disposals) 699

12


14 Expenses

15 less Operational expenditure 16,466

16

17 less Pass through and recoverable costs 2,417

18

19 Operating surplus / (deficit) 56,430

20

21 less Total depreciation 14,483

22

23 plus Total revaluation 7,548

24

25 Regulatory profit / (loss) before tax & term credit spread differential allowance 49,495

26

27 less Term credit spread differential allowance 96

28

29 Regulatory profit / (loss) before tax 49,400

30

31 less Regulatory tax allowance 10,123

32

33 Regulatory profit / (loss) 39,277

34

35 3(ii): Pass-Through and Recoverable Costs ($000)

36

37 Pass-through costs

38 Rates 1,956

39 Commerce Act levies 411

40 GIC levies

41 Other specified pass-through costs 50

42 Recoverable costs

43 Net recoverable costs allowed under incremental rolling incentive scheme -

44 Input Methodology claw-back -

45 Recoverable customised price-quality path costs -

46 Pass-through and recoverable costs 2,417

47

55 3(iii): Incremental Rolling Incentive Scheme56 CY-1 CY

57 30 Jun 13 30 Jun 14

58 Allowed controllable opex - -

59 Actual controllable opex - -

60

61 Incremental change in year -

62

63

Previous years'

incremental

change

Previous years'

incremental

change adjusted

for inflation

64 CY-5 30 Jun 09 - -

65 CY-4 30 Jun 10 - -

66 CY-3 30 Jun 11 - -

67 CY-2 30 Jun 12 - -

68 CY-1 30 Jun 13 - -

69 Net incremental rolling incentive scheme -

70

71 Net recoverable costs allowed under incremental rolling incentive scheme -

72

73 3(iv): Merger and Acquisition Expenditure74

75 Merger and acquisition expenses -

76

77

78 3(v): Other Disclosures79 Self-insurance allowance -

This schedule requires information on the calculation of regulatory profit for the GDB for the disclosure year. GDBs must complete all sections and must provide explanatory comment on their

regulatory profit in Schedule 14 (Mandatory Explanatory Notes).


Provide commentary on the benefits of merger and acquisition expenditure to the gas distribution business, including required disclosures in accordance with section 2.7, in

Schedule 14 (Mandatory Explanatory Notes)


30 June 2014

($000)

8 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S3.Regulatory Profit


Company Name

For Year Ended

SCHEDULE 4: REPORT ON VALUE OF THE REGULATORY ASSET BASE (ROLLED FORWARD)

sch ref

7 4(i): Regulatory Asset Base Value (Rolled Forward) RAB RAB RAB RAB RAB

8 for year ended 30 Jun 10 30 Jun 11 30 Jun 12 30 Jun 13 30 Jun 14

9 ($000) ($000) ($000) ($000) ($000)

10 Total opening RAB value 418,694 423,843 447,295 458,523 467,458

11

12 less Total depreciation 13,416 12,571 13,662 14,398 14,483

13

14 plus Total revaluations 6,925 13,596 4,248 3,134 7,548

15

16 plus Assets commissioned 12,363 22,745 20,664 20,404 23,068

17

18 less Asset disposals 723 328 48 190 50

19

20 plus Lost and found assets adjustment - - - - -

21

22 plus Adjustment resulting from asset allocation - 10 26 (15) 32

23

24 Total closing RAB value 423,843 447,295 458,523 467,458 483,573

25 4(ii): Unallocated Regulatory Asset Base26

27 ($000) ($000) ($000) ($000)

28 Total opening RAB value 493,247 467,458

29 less

30 Total depreciation 22,991 14,483

31 plus

32 Total revaluations 7,935 7,548

33 plus

34 Assets commissioned (other than below) 31,614 23,068

35 Assets acquired from a regulated supplier - -

36 Assets acquired from a related party - -

37 Assets commissioned 31,614 23,068

38 less

39 Asset disposals (other than below) 58 50

40 Asset disposals to a regulated supplier - -

41 Asset disposals to a related party - -

42 Asset disposals 58 50

43

44 plus Lost and found assets adjustment - -

45

46 plus Adjustment resulting from asset allocation 32

47

48 Total closing RAB value 509,747 483,573

49

This schedule requires information on the calculation of the Regulatory Asset Base (RAB) value to the end of this disclosure year. This informs the ROI calculation in Schedule 2. GDBs must provide explanatory comment on the value of their RAB in Schedule 14 (Mandatory Explanatory

Notes). This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8.

Unallocated RAB * RAB

* The 'unallocated RAB' is the total value of those assets used wholly or partially to provide gas distribution services without any allowance being made for the allocation of costs to non-regulated services. The RAB value represents the value of these assets after applying this

cost allocation. Neither value includes works under construction.


30 June 2014

9 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S4.RAB Value (Rolled Forward)


Company Name

For Year Ended


sch ref




30 June 2014

57 4(iii): Calculation of Revaluation Rate and Revaluation of Assets58

59 CPI4 1,195

60 CPI4-4 1,176

61 Revaluation rate (%) 1.62%

62

63

64 ($000) ($000) ($000) ($000)

65 Total opening RAB value 493,245 467,458

66 less Opening RAB value of fully depreciated, disposed and lost assets 2,084 253

67

68 Total opening RAB value subject to revaluation 491,161 467,205

69 Total revaluations 7,935 7,548

70

71 4(iv): Roll Forward of Works Under Construction

72

73 Works under construction—preceding disclosure year 2,790 1,360

74 plus Capital expenditure 37,825 28,417

75 less Assets commissioned 31,614 23,068

76 plus Adjustment resulting from asset allocation (113)

77 Works under construction - current disclosure year 9,001 6,595

78

79 Highest rate of capitalised finance applied 6.97%

RAB

Unallocated works under

construction Allocated works under construction

Unallocated RAB *



Company Name

For Year Ended


sch ref




30 June 2014

87 4(v): Regulatory Depreciation88 Unallocated RAB * RAB

89 ($000) ($000) ($000) ($000)

90 Depreciation - standard 12,902 12,902

91 Depreciation - no standard life assets 10,089 1,581

92 Depreciation - modified life assets

93 Depreciation - alternative depreciation in accordance with CPP

94 Total depreciation 22,991 14,483

95

96 4(vi): Disclosure of Changes to Depreciation Profiles($000 unless otherwise specified)

97

Depreciation

charge for the

period (RAB)

Closing RAB value

under 'non-

standard'

depreciation

Closing RAB value

under 'standard'

depreciation

98

99

100

101

102

103

104

105

106 * include additional rows if needed

107 4(vii): Disclosure by Asset Category

108

Intermediate

pressure main

pipelines

Medium pressure

main pipelines

Low pressure

main pipelines Service pipe Stations Line valve Special crossings

Other network

assets

Non-network

assets Total

109 Total opening RAB value 59,841 307,438 11,894 63,959 5,529 3,488 - 10,676 4,633 467,458

110 less Total depreciation 1,586 7,771 324 2,050 275 162 - 813 1,502 14,483

111 plus Total revaluations 966 4,966 192 1,031 89 56 - 176 72 7,548

112 plus Assets commissioned 822 9,493 243 7,617 1,156 558 78 1,935 1,166 23,068

113 less Asset disposals - - - - 23 9 - 18 - 50

114 plus Lost and found assets adjustment - - - - - - - - - -

115 plus Adjustment resulting from asset allocation - - - - - - - - 32 32

116 plus Asset category transfers (1,496) (3,293) (15) (111) (12) (2) 4,679 (471) 721 -

117 Total closing RAB value 58,547 310,833 11,990 70,446 6,464 3,929 4,757 11,485 5,122 483,573

118

119 Asset Life

120 Weighted average remaining asset life 41 43 42 46 29 40 37 19 10 (years)

121 Weighted average expected total asset life 71 60 60 60 35 62 64 45 15 (years)

Asset or assets with changes to depreciation Reason for non-standard depreciation (text entry)

($000 unless otherwise specified)



Company Name

For Year Ended

SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE

sch ref

7 5a(i): Regulatory Tax Allowance ($000)

8 Regulatory profit / (loss) before tax 49,400

9

10 plus Income not included in regulatory profit / (loss) before tax but taxable - *

11 Expenditure or loss in regulatory profit / (loss) before tax but not deductible 19 *

12 Amortisation of initial differences in asset values 4,123

13 Amortisation of revaluations 798

14 4,940

15

16 less Income included in regulatory profit / (loss) before tax but not taxable 7,548 *

18 Expenditure or loss deductible but not in regulatory profit / (loss) before tax *

19 Notional deductible interest 10,640

20 18,188

21

22 Regulatory taxable income 36,152

23

24 less Utilised tax losses -

25 Regulatory net taxable income 36,152

26

27 Corporate tax rate (%) 28%

28 Regulatory tax allowance 10,123

29

30 * Workings to be provided in Schedule 14

31

32 5a(ii): Disclosure of Permanent Differences33 In Schedule 14, Box 8, provide descriptions and workings of items recorded in the asterisked categories in Schedule 5a(i).

34 5a(iii): Amortisation of Initial Difference in Asset Values ($000)

35

36 Opening unamortised initial differences in asset values 160,816

37 Amortisation of initial differences in asset values 4,123

38 Adjustment for unamortised initial differences in assets acquired -

39 Adjustment for unamortised initial differences in assets disposed (72)

40 Closing unamortised initial difference in asset values 156,765

41

42 Opening weighted average remaining asset life (years) 39

43 5a(iv): Amortisation of Revaluations ($000)

44

45 Opening Sum of RAB values without revaluations 441,126

46

47 Adjusted depreciation 13,685

48 Total depreciation 14,483

49 Amortisation of revaluations 798

This schedule requires information on the calculation of the regulatory tax allowance.This information is used to calculate regulatory profit/loss in Schedule 3 (regulatory profit). GDBs

must provide explanatory commentary on the information disclosed in this schedule, in Schedule 14 (Mandatory Explanatory Notes).



30 June 2014

12 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5a.Regulatory Tax Allowance


Company Name

For Year Ended

SCHEDULE 5a: REPORT ON REGULATORY TAX ALLOWANCE

sch ref

This schedule requires information on the calculation of the regulatory tax allowance.This information is used to calculate regulatory profit/loss in Schedule 3 (regulatory profit). GDBs

must provide explanatory commentary on the information disclosed in this schedule, in Schedule 14 (Mandatory Explanatory Notes).



30 June 2014

57 5a(v): Reconciliation of Tax Losses ($000)

58

59 Opening tax losses -

60 plus Current period tax losses -

61 less Utilised tax losses -

62 Closing tax losses -

63 5a(vi): Calculation of Deferred Tax Balance ($000)

64

65 Opening deferred tax (19,014)

66

67 plus Tax effect of adjusted depreciation 3,832

68

69 less Tax effect of total tax depreciation 6,220

70

71 plus Tax effect of other temporary differences* 38

72

73 less Tax effect of amortisation of initial differences in asset values 1,155

74

75 plus Deferred tax balance relating to assets acquired in the disclosure year -

76

77 less Deferred tax balance relating to assets disposed in the disclosure year 22

78

79 plus Deferred tax cost allocation adjustment (4)

80

81 Closing deferred tax (22,545)

82

83 5a(vii): Disclosure of Temporary Differences

84

85

86 5a(viii): Regulatory Tax Asset Base Roll-Forward87 ($000)

88 Opening Sum of regulatory tax asset values 214,847

89 less Tax depreciation 22,215

90 plus Regulatory tax asset value of assets commissioned 23,830

91 less Regulatory tax asset value of asset disposals 129

92 plus Lost and found assets adjustment -

93 plus Other adjustments to the RAB tax value 43

94 Closing sum of regulatory tax asset values 216,376

In Schedule 14, Box 9, provide descriptions and workings of items recorded in the asterisked category in Schedule 5a(vi) (Tax effect of other temporary differences).

13 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5a.Regulatory Tax Allowance


Company Name

For Year Ended

SCHEDULE 5b: REPORT ON RELATED PARTY TRANSACTIONS

sch ref

7 5b(i): Summary—Related Party Transactions ($000)


9 Operational expenditure

10 Capital expenditure

11 Market value of asset disposals

12 Other related party transactions

13 5b(ii): Entities Involved in Related Party Transactions

14 Name of related party

15 Vector Gas Limited (gas wholesale)

16

17

18

19

20

* include additional rows if needed

21 5b(iii): Related Party Transactions

22 Name of related party

Related party

transaction

type

Value of

transaction

($000) Basis for determining value

23 Vector Gas Limited (gas wholesale) Sales 6,197

Clause 2.3.7 (2) (a) - price received by the GDB as

more than 50% of the GDB's sales are to third parties

who receive substantially the same terms, including

price, as the related party.

24 [Select one]

25 [Select one]

26 [Select one]

27 [Select one]

28 [Select one]

29 [Select one]

30 [Select one]

31 [Select one]

32 [Select one]

33 [Select one]

34 [Select one]

35 [Select one]

36 [Select one]

37 [Select one]

* include additional rows if needed


30 June 2014

This schedule provides information on the valuation of related party transactions, in accordance with section 2.3.6 and 2.3.7 of the ID determination.


Related party relationship

Sold distribution services

A fully owned unregulated business unit of Vector Gas Limited.

Description of transaction

14 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5b.Related Party Transactions


Company Name

For Year Ended

SCHEDULE 5c: REPORT ON TERM CREDIT SPREAD DIFFERENTIAL ALLOWANCE

sch ref

7

8 5c(i): Qualifying Debt (may be Commission only)9

10 Issuing party Issue date Pricing date

Original tenor (in

years) Coupon rate (%)

Book value at

issue date (NZD)

Book value at

date of financial

statements (NZD)

Term Credit

Spread Difference

Cost of executing

an interest rate

swap

Debt issue cost

readjustment

11 Senior bonds – fixed coupon 27-May-09 27-May-09 5.4 7.8 150,000 150,408 []VCI []VCI []VCI

Capital bonds – fixed coupon 15-Jun-12 14-Jun-12 5.0 7 262,651 262,316 []VCI []VCI []VCI

Floating rate notes 4-Apr-07 4-Apr-07 10 BKBM+ []VCI 200,000 []VCI []VCI []VCI

26-Oct-05 26-Oct-05 10 BKBM + []VCI 250,000 []VCI []VCI []VCI



Subtotal of floating rate notes 1,200,000 1,154,414

Medium term notes – GBP fixed rate 11-Apr-08 8-Apr-08 10.8 7.625 285,614 222,154 []VCI []VCI []VCI

Senior notes - USD fixed rate 16-Sep-04 19-Jul-04 12 5.51 98,875 []VCI []VCI []VCI

Senior notes - USD fixed rate 16-Sep-04 19-Jul-04 15 5.75 296,623 []VCI []VCI []VCI

Senior notes - USD fixed rate 20-Dec-10 22-Sep-10 12 []VCI 250,516 []VCI []VCI []VCI

Subtotal of senior notes - USD fixed rate 646,014 551,361

Bank loans 3-Feb-12 3-Feb-12 3 BKBM + []VCI

3-Feb-12 3-Feb-12 3 BKBM + []VCI

17-Dec-13 17-Dec-13 3 BKBM + []VCI

Subtotal of bank loans 99,797

Working capital and other loans 17-Dec-13 17-Dec-13 3 BKBM + []VCI

17-Dec-13 17-Dec-13 3 BKBM + []VCI

17-Dec-13 17-Dec-13 3 BKBM + []VCI

Subtotal of working capital and other

loans

28,538

16 * include additional rows if needed 2,468,988 []VCI []VCI []VCI

17

18 5c(ii): Attribution of Term Credit Spread Differential19

20 Gross term credit spread differential 1,106

21

22 Total book value of interest bearing debt 2,420,430

23 Leverage 44%

24 Average opening and closing RAB values 475,516

25 Attribution Rate (%) 9%

26

27 Term credit spread differential allowance 96


30 June 2014

This schedule is only to be completed if, as at the date of the most recently published financial statements, the weighted average original tenor of the debt portfolio (both qualifying debt and non-qualifying debt) is

greater than five years. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8.

15 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5c.TCSD Allowance


Company Name

For Year Ended

SCHEDULE 5d: REPORT ON COST ALLOCATIONS

sch ref

7 5d(i): Operating Cost Allocations8

9

Arm's length

deduction

Gas distribution

services

Non-gas

distribution

services Total

10 Service interruptions, incidents and emergencies

11 Directly attributable 3,732

12 Not directly attributable - - - - -

13 Total attributable to regulated service 3,732

14 Routine and corrective maintenance and inspection




18 Asset replacement and renewal

19 Directly attributable -


21 Total attributable to regulated service -

22 System operations and network support


24 Not directly attributable - 714 3,920 4,634 -


26 Business support

27 Directly attributable 165

28 Not directly attributable - 6,132 39,093 45,225 -


30

31 Operating costs directly attributable 9,620

32 Operating costs not directly attributable - 6,846 43,013 49,859 -

33 Operating expenditure 16,466

41 5d(ii): Other Cost Allocations

42 Pass through and recoverable costs

43 Pass through costs




47 Recoverable costs

48 Directly attributable


50 Total attributable to regulated service -

51

52 5d(iii): Changes in Cost Allocations* † CY-1 Current Year (CY)

53 Change in cost allocation 1 30 Jun 13 30 Jun 14

54 Cost category Original allocation

55 Original allocator or line items New allocation

56 New allocator or line items Difference - -

57

58 Rationale for change

59

60 CY-1 Current Year (CY)





65


67

68 CY-1 Current Year (CY)





73


75

76

† include additional rows if needed

This schedule provides information on the allocation of operational costs. GDBs must provide explanatory comment on their cost allocation in Schedule 14 (Mandatory Explanatory Notes), including on the impact of any reclassifications.


($000)

* a change in cost allocation must be completed for each cost allocator change that has occurred in the disclosure year. A movement in an allocator metric is not a change in allocator or component.


30 June 2014

Value allocated ($000s)

OVABAA

allocation

increase ($000s)

16 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5d.Cost Allocations


Company Name

For Year Ended

SCHEDULE 5e: REPORT ON ASSET ALLOCATIONS

sch ref

7 5e(i):Regulated Service Asset Values

8

Value allocated

($000s)

9

Gas distribution

services

10 Main pipe


12 Not directly attributable -


14 Service pipe




18 Stations




22 Line valve




26 Special crossings




30 Other network assets




34 Non-network assets


36 Not directly attributable 3,844


38

39 Regulated service asset value directly attributable 479,729

40 Regulated service asset value not directly attributable 3,844

41 Total closing RAB value 483,573

42

50 5e(ii): Changes in Asset Allocations* †51 CY-1 Current Year (CY)

52 Change in asset value allocation 1 30 Jun 13 30 Jun 14

53

54 Asset category Original allocation



57


59

CY-1 Current Year (CY)





64


66

CY-1 Current Year (CY)





71


73

74

† include additional rows if needed

* a change in asset allocation must be completed for each allocator or component change that has occurred in the disclosure year. A movement in an allocator metric is not a change in allocator or component.


30 June 2014

This schedule requires information on the allocation of asset values. This information supports the calculation of the RAB value in Schedule 4. GDBs must provide explanatory comment on their cost allocation in Schedule 14 (Mandatory

Explanatory Notes), including on the impact of any changes in asset allocations. This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by

section 2.8.

($000)

17 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S5e.Asset Allocations


Company Name

For Year Ended

SCHEDULE 6a: REPORT ON CAPITAL EXPENDITURE FOR THE DISCLOSURE YEAR

sch ref

7 6a(i): Expenditure on Assets ($000) ($000)

8 Consumer connection 16,316

9 System growth 1,432

10 Asset replacement and renewal 9,686

11 Asset relocations 2,294

12 Reliability, safety and environment:

13 Quality of supply 654

14 Legislative and regulatory -

15 Other reliability, safety and environment 838

16 Total reliability, safety and environment 1,492

17 Expenditure on network assets 31,221

18 Non-network assets 1,300 19

20 Expenditure on assets 32,521

21 plus Cost of financing 113

22 less Value of capital contributions 4,217

23 plus Value of vested assets -24

25 Capital expenditure 28,417

26 6a(ii): Subcomponents of Expenditure on Assets (where known) ($000)

27 Research and development -

28 6a(iii): Consumer Connection29 Consumer types defined by GDB* ($000) ($000)

30 Mains Extensions/Subdivsions 8,660

31 Service Connections - Residential 6,510

32 Service Connections - Commercial 1,145

33 Customer Easements 1

34 -


36 Consumer connection expenditure 16,316 37

38 less Capital contributions funding consumer connection expenditure 1,832

39 Consumer connection less capital contributions 14,485

This schedule requires a breakdown of capital expenditure on assets incurred in the disclosure year, including any assets in respect of which capital contributions are received, but excluding

assets that are vested assets. Information on expenditure on assets must be provided on an accounting accruals basis and must exclude finance costs.

GDBs must provide explanatory comment on their expenditure on assets in Schedule 14 (Explanatory notes to templates).



30 June 2014

18 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S6a.Actual Expenditure Capex


Company Name

For Year Ended


sch ref






30 June 2014

47 6a(iv): System Growth and Asset Replacement and Renewal

48 System Growth

49 ($000) ($000)

50 Intermediate pressure

51 Main pipe - -

52 Service pipe - -

53 Stations 698 936

54 Line valve 83 90

55 Special crossings - 4

56 Intermediate pressure -total 781 1,030

57 Medium pressure

58 Main pipe 651 7,462

59 Service pipe - 164

60 Stations - 56

61 Line valve - -

62 Special crossings - 113

63 Medium pressure - total 651 7,795

64 Low pressure

65 Main pipe - -

66 Service pipe - -

67 Line valve - -

68 Special crossings - -

69 Low pressure - total - -

70 Other network assets

71 Monitoring and control systems - 96

72 Cathodic protection systems - 462

73 Other - 303

74 Other network assets - total - 861

75

76 System growth and asset replacement and renewal expenditure 1,432 9,686

77 less Capital contributions funding system growth and asset replacement and renewal - -

78 System growth and asset replacement and renewal less capital contributions 1,432 9,686

79 6a(v): Asset Relocations80 Project or programme* ($000) ($000)

81 Waterview Connection 566

82 [Description of material project or programme]





87 All other asset relocations projects or programmes 1,728

88 Asset relocations expenditure 2,294

89 less Capital contributions funding asset relocations 2,385

90 Asset relocations less capital contributions (91)

91 6a(vi): Quality of Supply92 Project or programme* ($000) ($000)

93 [Description of material project or programme] -






99 All other quality of supply projects or programmes 654

100 Quality of supply expenditure 654

101 less Capital contributions funding quality of supply -

102 Quality of supply less capital contributions 654

Asset

Replacement and

Renewal



Company Name

For Year Ended


sch ref






30 June 2014

110 6a(vii): Legislative and Regulatory111 Project or programme* ($000) ($000)







118 All other legislative and regulatory projects or programmes -

119 Legislative and regulatory expenditure -

120 less Capital contributions funding legislative and regulatory -

121 Legislative and regulatory less capital contributions -

122

123 6a(viii): Other Reliability, Safety and Environment124 Project or programme* ($000) ($000)

125 Tuhikaramea Rd: IP pipeline protection HM 609






131 All other reliability, safety and environment projects or programmes 229

132 Other reliability, safety and environment expenditure 838

133 less Capital contributions funding other reliability, safety and environment -

134 Other reliability, safety and environment less capital contributions 838

135 6a(ix): Non-Network Assets136 Routine expenditure

137 Project or programme* ($000) ($000)







144 All other routine expenditure projects or programmes 294

145 Routine expenditure 294

146 Atypical expenditure

147 Project or programme* ($000) ($000)







154 All other atypical expenditure projects or programmes 1,006

155 Atypical expenditure 1,006

156

157 Non-network assets expenditure 1,300



Company Name

For Year Ended

SCHEDULE 6b: REPORT ON OPERATIONAL EXPENDITURE FOR THE DISCLOSURE YEAR

sch ref

7 6b(i): Operational Expenditure ($000) ($000)

8 Service interruptions, incidents and emergencies 3,732

9 Routine and corrective maintenance and inspection 3,782

10 Asset replacement and renewal -

11 Network opex 7,514

12 System operations and network support 2,655

13 Business support 6,297

14 Non-network opex 8,952

15

16 Operational expenditure 16,466

17 6b(ii): Subcomponents of Operational Expenditure (where known)18 Research and development -

19 Insurance 224


30 June 2014

This schedule requires a breakdown of operating expenditure incurred in the current disclosure year. GDBs must provide explanatory comment on their operational

expenditure in Schedule 14 (Explanatory notes to templates). This includes explanatory comment on any atypical operating expenditure and assets replaced or renewed as

part of asset replacement and renewal operational expenditure, and additional information on insurance.

This information is part of audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section

2.8.

21 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S6b.Actual Expenditure Opex


Company Name

For Year Ended

SCHEDULE 7: COMPARISON OF FORECASTS TO ACTUAL EXPENDITURE

sch ref

8 7(i): Revenue Target ($000) ¹ Actual ($000) % variance

9 Line charge revenue 69,155 74,664 8%

10 7(ii): Expenditure on Assets Forecast ($000) ² Actual ($000) % variance

11 Consumer connection 10,446 16,316 56%

12 System growth 3,689 1,432 (61%)

13 Asset replacement and renewal 12,858 9,686 (25%)

14 Asset relocations 4,006 2,294 (43%)

15 Reliability, safety and environment:

16 Quality of supply 613 654 7%

17 Legislative and regulatory - - -

18 Other reliability, safety and environment - 838 -

19 Total reliability, safety and environment 613 1,492 143%

Expenditure on network assets 31,612 31,221 (1%)

21 Non-network capex 1,708 1,300 (24%)

22 Expenditure on assets 33,320 32,521 (2%)

23 7(iii): Operational Expenditure 24 Service interruptions, incidents and emergencies 4,149 3,732 (10%)

25 Routine and corrective maintenance and inspection 4,704 3,782 (20%)

26 Asset replacement and renewal - - -

27 Network opex 8,853 7,514 (15%)

28 System operations and network support 4,146 2,655 (36%)

29 Business support 8,210 6,297 (23%)

30 Non-network opex 12,356 8,952 (28%)

31 Operational expenditure 21,209 16,466 (22%)

32 7(iv): Subcomponents of Expenditure on Assets (where known)33 Research and development - - -

34 7(v): Subcomponents of Operational Expenditure (where known)35 Research and development - - -

36 Insurance 239 224 (6%)

37 1 From the nominal dollar target revenue for the disclosure year disclosed under clause 2.4.3(3) of the Determination

38 2 From the nominal dollar expenditure forecast and disclosed in the second to last AMP as the year CY+1 forecast

This schedule compares actual revenue and expenditure to the previous forecasts that were made for the disclosure year. Accordingly, this schedule

requires the forecast revenue and expenditure information from previous disclosures to be inserted.

GDBs must provide explanatory comment on the variance between actual and target revenue and forecast expenditure in Schedule 14 (Mandatory

Explanatory Notes). This information is part of the audited disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the

assurance report required by section 2.8. For the purpose of this audit, target revenue and forecast expenditures only need to be verified back to previous

disclosures.


30 June 2014

22 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S7.Actual vs Forecast Exp


Company Name

For Year Ended

Network / Sub-Network Name

SCHEDULE 8: REPORT ON BILLED QUANTITIES AND LINE CHARGE REVENUES

sch ref

8 8(i): Billed quantities by price component

9 Billed quantities by price component

10

Price component Fixed Variable

11

Consumer group name or price

category code

Consumer type or types (eg, residential,

commercial, etc.)

Standard or non-standard

consumer group (specify)

Average no. of ICPs in

disclosure year

Quantity of gas

delivered to ICPs (TJ per

annum) in disclosure

year

Unit charging

basis (eg, days, GJ,

etc.)

Days kWh

12

13 GA0R Residential Standard 88,046 2,119 32,105,913 588,524,914

14 GA01 Commercial Standard 2,236 213 813,582 59,174,239


16 GA03 Commercial Standard 869 1,774 316,432 492,904,167


18 GN0R Residential Standard 60,452 1,252 22,037,837 347,827,104

19 GN01 Commercial Standard 2,118 161 772,691 44,762,007


21 GN03 Commercial Standard 509 843 185,799 234,100,965


23 Non-standard Commercial Non-standard 92 11,287 31,824 3,135,410,638

24

25 Add extra rows for additional consumer groups or price category codes as necessary

26 Standard consumer totals 158,242 10,455 57,695,985 2,904,196,032 - - -

27 Non-standard consumer totals 92 11,287 31,824 3,135,410,638 - - -

28 Total for all consumers 158,334 21,742 57,727,809 6,039,606,670 - - -29

38 8(ii): Line charge revenues ($000) by price component39 Line charge revenues ($000) by price component

40


41


category code


commercial, etc.)



Total line charge

revenue in disclosure

year

Notional revenue

foregone (if applicable)

Rate (eg, $/day,

$/GJ, etc.)$/Day $/kWh

42

43 GA0R Residential Standard $25,755 $9,485 $16,270

44 GA01 Commercial Standard $1,578 $389 $1,189


46 GA03 Commercial Standard $6,493 $1,258 $5,235


48 GN0R Residential Standard $15,942 $6,350 $9,592

49 GN01 Commercial Standard $1,247 $355 $892

50 GN02 Commercial Standard $2,316 $392 $1,924



53 Non-standard Commercial Non-standard $6,772 $5,059 $1,713

54 [Select one] -


56 Standard consumer totals $67,892 - $20,745 $47,147 - - -

57 Non-standard consumer totals $6,772 - $5,059 $1,713 - - -

58 Total for all consumers $74,664 - $25,804 $48,860 - - -

Add extra columns

for additional

billed quantities

by price

component as

necessary

This schedule requires the billed quantities and associated line charge revenues for the disclosure year for each consumer group or price category code used by the GDB in its pricing schedules. Information is also required on the number of ICPs that are included in each consumer group or price

category code, and the energy delivered to these ICPs.

Add extra columns

for additional line

charge revenues

by price

component as

necessary


30 June 2014

Combined

23 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S8.Billed Q+R combined


Company Name

For Year Ended



sch ref



10


11


category code


commercial, etc.)




disclosure year

Quantity of gas



year

Unit charging


etc.)

Days kWh

12

13 GN0R Residential Standard 60,452 1,252 22,037,837 347,827,104






19

20

21

22

23

24






40


41


category code


commercial, etc.)



Total line charge


year

Notional revenue


Rate (eg, $/day,


42

43 GN0R Residential Standard $15,942 $6,350 $9,592

44 GN01 Commercial Standard $1,247 $355 $892




48 Non-standard Commercial Non-standard $2,307 $1,856 $451

49 -

50 -

51 -

52 -

53 -

54 -



57 Non-standard consumer totals $2,307 - $1,856 $451 - - -


Add extra columns

for additional line

charge revenues

by price

component as

necessary


30 June 2014

North Island



Add extra columns

for additional

billed quantities

by price

component as

necessary

24 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S8.Billed Q+R North Island


Company Name

For Year Ended



sch ref



10


11


category code


commercial, etc.)




disclosure year

Quantity of gas



year

Unit charging


etc.)

Days kWh

12

13 GA0R Residential Standard 88,046 2,119 32,105,913 588,524,914






19

20

21

22

23

24






40


41


category code


commercial, etc.)



Total line charge


year

Notional revenue


Rate (eg, $/day,


42

43 GA0R Residential Standard $25,755 $9,485 $16,270



46 GA03 Commercial Standard $6,493 $1,258 $5,235


48 Non-standard Commercial Non-standard $4,465 $3,204 $1,262

49 -

50 -

51 -

52 -

53 -

54 -



57 Non-standard consumer totals $4,465 - $3,204 $1,262 - - -


Add extra columns

for additional line

charge revenues

by price

component as

necessary


30 June 2014

Auckland



Add extra columns

for additional

billed quantities

by price

component as

necessary

25 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S8.Billed Q+R Auckland


Company Name

For Year Ended

Network / Sub-network Name

SCHEDULE 9a: ASSET REGISTER

sch ref

8 Operating Pressure Asset Category Asset Class Units

Items at start of

year (quantity)

Items at end of

year (quantity) Net change

Data accuracy

(1–4)

9 Intermediate Pressure Main pipe IP PE main pipe km 0 km 0 km - N/A

10 Intermediate Pressure Main pipe IP steel main pipe km 404 km 404 km (0) 4

11 Intermediate Pressure Main pipe IP other main pipe km 0 km 0 km - N/A

12 Intermediate Pressure Service pipe IP PE service pipe km 0 km 0 km 0 N/A

13 Intermediate Pressure Service pipe IP steel service pipe km 8 km 8 km (0) 3

14 Intermediate Pressure Service pipe IP other service pipe km 0 km 0 km - N/A

15 Intermediate Pressure Stations Intermediate pressure DRS No. 206 200 (6) 4

16 Intermediate Pressure Line valve IP line valves No. 892 918 26 3

17 Intermediate Pressure Special crossings IP crossings No. 44 40 (4) 3

18 Medium Pressure Main pipe MP PE main pipe km 6,257 km 6,362 km 106 4

19 Medium Pressure Main pipe MP steel main pipe km 366 km 362 km (4) 4

20 Medium Pressure Main pipe MP other main pipe km 2 km 2 km - 4

21 Medium Pressure Service pipe MP PE service pipe km 3,279 km 3,343 km 64 3

22 Medium Pressure Service pipe MP steel service pipe km 46 km 45 km (2) 3

23 Medium Pressure Service pipe MP other service pipe km 5 km 5 km (0) 3

24 Medium Pressure Stations Medium pressure DRS No. 284 246 (38) 4

25 Medium Pressure Line valve MP line valves No. 3,858 3,895 37 3

26 Medium Pressure Special crossings MP special crossings No. 102 121 19 3

27 Low Pressure Main pipe LP PE main pipe km 48 km 43 km (5) 3

28 Low Pressure Main pipe LP steel main pipe km 11 km 6 km (5) 3

29 Low Pressure Main pipe LP other main pipe km 19 km 0 km (18) 3

30 Low Pressure Service pipe LP PE service pipe km 49 km 39 km (10) 3

31 Low Pressure Service pipe LP steel service pipe km 7 km 5 km (3) 3

32 Low Pressure Service pipe LP other service pipe km 0 km 0 km (0) 3

33 Low Pressure Line valve LP line valves No. 34 29 (5) 3

34 Low Pressure Special crossings LP special crossings No. 1 0 (1) 3

35 All Monitoring & control systems Remote terminal units No. 66 72 6 4

36 All Cathodic protection systems Cathodic protection No. 54 54 - 3


30 June 2014

This schedule requires a summary of the quantity of assets that make up the network, by asset category and asset class.

Combined

26 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9a.Asset Register combined


Company Name

For Year Ended



sch ref


Items at start of

year (quantity)

Items at end of


Data accuracy

(1–4)


10 Intermediate Pressure Main pipe IP steel main pipe km 194 km 193 km (1) 4


12 Intermediate Pressure Service pipe IP PE service pipe km 0 km 0 km - N/A












24 Medium Pressure Stations Medium pressure DRS No. 25 26 1 4








32 Low Pressure Service pipe LP other service pipe km 0 km 0 km - 3

33 Low Pressure Line valve LP line valves No. 12 14 2 3

34 Low Pressure Special crossings LP special crossings No. 0 0 - 3




30 June 2014

North Island


27 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9a.Asset Register North Island


Company Name

For Year Ended



sch ref


Items at start of

year (quantity)

Items at end of


Data accuracy

(1–4)


10 Intermediate Pressure Main pipe IP steel main pipe km 210 km 210 km 1 4


12 Intermediate Pressure Service pipe IP PE service pipe km 0 km 0 km 0 N/A












24 Medium Pressure Stations Medium pressure DRS No. 259 220 (39) 4








32 Low Pressure Service pipe LP other service pipe km 0 km 0 km (0) 3

33 Low Pressure Line valve LP line valves No. 22 15 (7) 3

34 Low Pressure Special crossings LP special crossings No. 1 0 (1) 3




30 June 2014

Auckland


28 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9a.Asset Register Auckland


Company Name

For Year Ended


SCHEDULE 9b: ASSET AGE PROFILE

sch ref

8 Disclosure Year (year ended) 30 June 2014

9 Operating Pressure Asset Category Asset Class Units pre-1970

1970

–1974

1975

–1979

1980

–1984

1985-

1989

1990

–1994

1995

–1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

No. with age

unknown

Total

assets at

year end

No. with

default dates

Data accuracy

(1–4)

10 Intermediate Pressure Main pipe IP PE main pipe km - N/A

11 Intermediate Pressure Main pipe IP steel main pipe km 47 km 31 km 5 km 95 km 121 km 22 km 49 km 25 km 0 km 1 km 0 km 0 km 1 km 1 km 1 km 0 km 0 km 1 km 0 km 1 km 0 km 1 km 0 km 404 3

12 Intermediate Pressure Main pipe IP other main pipe km - N/A

13 Intermediate Pressure Service pipe IP PE service pipe km 0 km 0 N/A

14 Intermediate Pressure Service pipe IP steel service pipe km 0 km 0 km 0 km 1 km 2 km 2 km 2 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 8 3

15 Intermediate Pressure Service pipe IP other service pipe km - N/A

16 Intermediate Pressure Stations Intermediate pressure DRS No. 7 3 8 40 41 14 56 1 4 3 4 2 1 2 1 4 2 1 5 1 200 2

17 Intermediate Pressure Line valve IP line valves No. 62 52 22 113 259 124 75 18 10 5 6 8 14 8 10 11 5 10 11 20 11 34 30 918 2

18 Intermediate Pressure Special crossings IP crossings No. 3 1 10 14 1 6 1 1 1 1 1 40 3

19 Medium Pressure Main pipe MP PE main pipe km 14 km 25 km 169 km 247 km 889 km 1,048 km 1,912 km 246 km 148 km 124 km 192 km 175 km 190 km 176 km 160 km 132 km 72 km 63 km 71 km 76 km 118 km 111 km 4 km 6,362 3

20 Medium Pressure Main pipe MP steel main pipe km 18 km 115 km 44 km 92 km 79 km 5 km 5 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 362 3

21 Medium Pressure Main pipe MP other main pipe km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 2 3

22 Medium Pressure Service pipe MP PE service pipe km 4 km 21 km 98 km 72 km 235 km 550 km 913 km 148 km 99 km 96 km 123 km 138 km 116 km 119 km 109 km 91 km 55 km 62 km 81 km 68 km 72 km 72 km 1 km 3,343 3

23 Medium Pressure Service pipe MP steel service pipe km 2 km 14 km 3 km 8 km 8 km 4 km 5 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 45 3

24 Medium Pressure Service pipe MP other service pipe km 0 km 1 km 0 km 0 km 3 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 5 3

25 Medium Pressure Stations Medium pressure DRS No. 1 6 3 10 43 93 40 4 1 1 10 5 6 2 1 2 2 3 9 2 2 246 3

26 Medium Pressure Line valve MP line valves No. 57 289 226 925 819 478 300 52 44 43 32 39 64 42 39 38 46 26 49 59 70 67 91 3,895 2

27 Medium Pressure Special crossings MP special crossings No. 1 2 17 38 17 20 7 1 1 3 2 3 3 2 3 1 121 3

28 Low Pressure Main pipe LP PE main pipe km 2 km 21 km 2 km 3 km 4 km 2 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 5 km 0 km 43 3

29 Low Pressure Main pipe LP steel main pipe km 1 km 4 km 1 km 0 km 0 km 0 km 0 km 0 km 6 3

30 Low Pressure Main pipe LP other main pipe km 0 km 0 km 0 km 0 km 0 2

31 Low Pressure Service pipe LP PE service pipe km 0 km 2 km 9 km 5 km 4 km 5 km 4 km 0 km 1 km 0 km 0 km 0 km 0 km 0 km 1 km 1 km 0 km 0 km 0 km 1 km 2 km 1 km 0 km 39 3

32 Low Pressure Service pipe LP steel service pipe km 1 km 2 km 0 km 1 km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 5 3

33 Low Pressure Service pipe LP other service pipe km 0 km 0 km 0 3

34 Low Pressure Line valve LP line valves No. 2 2 4 4 3 1 2 6 2 3 29 2

35 Low Pressure Special crossings LP special crossings No. - 4

36 All Monitoring & control systems Remote terminal units No. 32 1 1 1 4 1 19 3 2 1 1 6 72 4

37 All Cathodic protection systems Cathodic protection No. 1 2 2 10 21 8 3 2 1 1 1 2 54 3


30 June 2014

Combined

This schedule requires a summary of the age profile (based on year of installation) of the assets that make up the network, by asset category and asset class.

Number of assets at disclosure year end by installation date

29 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9b.Asset Age Profile combined


Company Name

For Year Ended



sch ref



1970

–1974

1975

–1979

1980

–1984

1985-

1989

1990

–1994

1995

–1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

No. with age

unknown

Total

assets at

year end

No. with

default dates

Data accuracy

(1–4)


11 Intermediate Pressure Main pipe IP steel main pipe km 1 km 16 km 1 km 79 km 69 km 10 km 15 km 0 km 0 km 0 km 0 km 1 km 0 km 0 km 0 km 0 km 0 km 1 km 0 km 0 km 0 km 193 3


13 Intermediate Pressure Service pipe IP PE service pipe km - N/A

14 Intermediate Pressure Service pipe IP steel service pipe km 0 km 1 km 1 km 0 km 0 km 0 km 2 3


16 Intermediate Pressure Stations Intermediate pressure DRS No. 1 1 1 33 39 11 3 2 2 4 1 2 1 3 1 3 1 109 2

17 Intermediate Pressure Line valve IP line valves No. 13 4 48 74 23 10 3 2 1 1 6 8 2 6 4 1 1 5 11 3 9 235 2

18 Intermediate Pressure Special crossings IP crossings No. 1 9 7 1 3 1 22 3

19 Medium Pressure Main pipe MP PE main pipe km 0 km 22 km 152 km 187 km 713 km 539 km 525 km 98 km 61 km 68 km 73 km 92 km 96 km 59 km 68 km 75 km 37 km 23 km 17 km 25 km 49 km 44 km 1 km 3,023 3

20 Medium Pressure Main pipe MP steel main pipe km 7 km 92 km 30 km 16 km 5 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 149 3

21 Medium Pressure Main pipe MP other main pipe km 0 km 0 3


23 Medium Pressure Service pipe MP steel service pipe km 0 km 13 km 1 km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 16 3

24 Medium Pressure Service pipe MP other service pipe km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 1 3

25 Medium Pressure Stations Medium pressure DRS No. 4 1 2 1 1 2 1 1 2 2 7 1 1 26 3


27 Medium Pressure Special crossings MP special crossings No. 9 26 8 7 2 1 1 1 1 1 1 58 3

28 Low Pressure Main pipe LP PE main pipe km 2 km 21 km 2 km 3 km 4 km 2 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 5 km 0 km 42 3

29 Low Pressure Main pipe LP steel main pipe km 1 km 4 km 1 km 0 km 0 km 0 km 6 3

30 Low Pressure Main pipe LP other main pipe km - 2

31 Low Pressure Service pipe LP PE service pipe km 0 km 2 km 9 km 5 km 3 km 4 km 4 km 0 km 1 km 0 km 0 km 0 km 0 km 0 km 1 km 1 km 0 km 0 km 0 km 1 km 2 km 1 km 0 km 36 3

32 Low Pressure Service pipe LP steel service pipe km 0 km 2 km 0 km 0 km 2 3

33 Low Pressure Service pipe LP other service pipe km - N/A

34 Low Pressure Line valve LP line valves No. 2 1 6 2 3 14 2

35 Low Pressure Special crossings LP special crossings No. - N/A


37 All Cathodic protection systems Cathodic protection No. 1 6 18 8 1 1 1 1 2 39 3


30 June 2014

North Island



30 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9b.Asset Age Profile North Isl


Company Name

For Year Ended



sch ref



1970

–1974

1975

–1979

1980

–1984

1985-

1989

1990

–1994

1995

–1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

No. with age

unknown

Total

assets at

year end

No. with

default dates

Data accuracy

(1–4)


11 Intermediate Pressure Main pipe IP steel main pipe km 47 km 14 km 4 km 16 km 52 km 13 km 35 km 25 km 0 km 1 km 0 km 0 km 1 km 1 km 0 km 0 km 0 km 0 km 1 km 0 km 1 km 210 3


13 Intermediate Pressure Service pipe IP PE service pipe km 0 km 0 N/A

14 Intermediate Pressure Service pipe IP steel service pipe km 0 km 0 km 0 km 0 km 2 km 2 km 2 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 6 3


16 Intermediate Pressure Stations Intermediate pressure DRS No. 6 2 7 7 2 3 53 1 2 1 1 1 1 2 2 91 2

17 Intermediate Pressure Line valve IP line valves No. 62 39 18 65 185 101 65 15 8 4 5 2 6 6 4 7 4 9 6 9 8 25 30 683 2

18 Intermediate Pressure Special crossings IP crossings No. 3 1 7 3 1 1 1 1 18 3

19 Medium Pressure Main pipe MP PE main pipe km 13 km 3 km 17 km 61 km 176 km 509 km 1,387 km 149 km 87 km 56 km 119 km 83 km 94 km 117 km 91 km 57 km 36 km 40 km 55 km 51 km 69 km 67 km 3 km 3,340 3

20 Medium Pressure Main pipe MP steel main pipe km 11 km 24 km 14 km 76 km 75 km 5 km 5 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 213 3

21 Medium Pressure Main pipe MP other main pipe km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 2 3


23 Medium Pressure Service pipe MP steel service pipe km 2 km 1 km 2 km 7 km 7 km 4 km 5 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 29 3

24 Medium Pressure Service pipe MP other service pipe km 0 km 0 km 0 km 0 km 3 km 0 km 0 km 0 km 0 km 0 km 0 km 4 3

25 Medium Pressure Stations Medium pressure DRS No. 1 2 2 8 42 92 38 4 1 1 10 4 6 2 1 1 1 2 1 1 220 3


27 Medium Pressure Special crossings MP special crossings No. 1 2 8 12 9 13 5 3 1 2 3 2 2 63 3

28 Low Pressure Main pipe LP PE main pipe km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 3

29 Low Pressure Main pipe LP steel main pipe km 0 km 0 km 0 km 0 km 0 3

30 Low Pressure Main pipe LP other main pipe km 0 km 0 km 0 km 0 km 0 2

31 Low Pressure Service pipe LP PE service pipe km 0 km 0 km 0 km 0 km 1 km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 0 km 3 3

32 Low Pressure Service pipe LP steel service pipe km 1 km 0 km 0 km 1 km 1 km 0 km 0 km 0 km 0 km 0 km 0 km 3 3

33 Low Pressure Service pipe LP other service pipe km 0 km 0 km 0 3

34 Low Pressure Line valve LP line valves No. 2 4 3 3 1 2 15 2

35 Low Pressure Special crossings LP special crossings No. - 4

36 All Monitoring & control systems Remote terminal units No. 32 1 1 1 4 1 19 3 2 1 3 68 4

37 All Cathodic protection systems Cathodic protection No. 1 1 2 4 3 2 1 1 15 3


30 June 2014

Auckland



31 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9b.Asset Age Profile Auckland


Company Name

For Year Ended


SCHEDULE 9c: REPORT ON PIPELINE DATA

sch ref

8 Network Information (end of year)9 Length of pipeline by material (defined by GDB) Length (km) %

10 STEEL 829 7.8%

11 PE 9,787 92.1%

12 OTHER 7 0.1%

13 -

14 -

15 -

16 Total length of pipeline 10,623 100.0%

17

18 By operating pressure:

Pipe length (km)

(at year end)

Weighted average

pipe diameter

(mm)

Number of ICPs

(at year end)

Gas conveyed for

Persons not

involved in the

GDB (TJ)

19 Intermediate pressure 412 km 129.0 220 5,713

20 Medium pressure 10,119 km 36.3 152,184 11,050

21 Low pressure 93 km 38.6 7,334 349

22 Total 10,623 40 159,738 17,112

This schedule requires a summary of the key characteristics of the pipeline network.


30 June 2014

Combined

32 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9c.Pipeline Data combined


Company Name

For Year Ended



sch ref


10 STEEL 368 7.6%

11 PE 4,458 92.4%

12 OTHER 1 0.0%

13 -

14 -

15 -


17


Pipe length (km)

(at year end)

Weighted average

pipe diameter

(mm)

Number of ICPs

(at year end)

Gas conveyed for

Persons not

involved in the

GDB (TJ)



21 Low pressure 86 km 38.0 1,892 60

22 Total 4,827 37 64,917 6,618


30 June 2014

North Island


33 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9c.Pipeline Data North Island


Company Name

For Year Ended



sch ref


10 STEEL 461 8.0%

11 PE 5,328 91.9%

12 OTHER 6 0.1%

13 -

14 -

15 -


17


Pipe length (km)

(at year end)

Weighted average

pipe diameter

(mm)

Number of ICPs

(at year end)

Gas conveyed for

Persons not

involved in the

GDB (TJ)



21 Low pressure 6 km 46.5 5,442 289

22 Total 5,795 42 94,821 10,494


30 June 2014

Auckland


34 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9c.Pipeline Data Auckland


Company Name

For Year Ended


SCHEDULE 9d: REPORT ON DEMAND

sch ref

8

9 9d(i): Consumer Connections10 Number of ICPs connected in year by consumer type

11

12 Consumer types defined by GDB

Number of

connections (ICPs)

13 3,764

14 282

15

16

17

18 Total 4,046

19 9d(ii): Gas Delivered 20

21 Number of ICPs at year end 159,738 connections

22 Maximum daily load 85,392 (GJ/day)

23 Maximum monthly load 2,150,228 (GJ/month)

24 Number of directly billed ICPs 1 (at year end)

25 Total gas conveyed 21,934,671 (GJ/annum)

26 Average daily delivery 60,095 (GJ/day)

27

28 Maximum monthly amount of gas entering network (GJ/month) 2,150,228

29 Load factor 85.01%


30 June 2014

Residential

Commercial

This schedule requires a summary of the key measures of network demand for the disclosure year (number of new connections

including, maximum monthly loads and total gas conveyed)

combined

35 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9d.Demand combined


Company Name

For Year Ended



sch ref

8


11


Number of

connections (ICPs)

13 1,332

14 102

15

16

17

18 Total 1,434




23 Maximum monthly load 979,954 (GJ/month)

24 Number of directly billed ICPs - (at year end)



27

28 Maximum monthly amount of gas entering network (GJ/month) 979,954



30 June 2014

North Island



Residential

Commercial

36 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9d.Demand North Island


Company Name

For Year Ended



sch ref

8


11


Number of

connections (ICPs)

13 2,432

14 180

15

16

17

18 Total 2,612




23 Maximum monthly load 1,277,932 (GJ/month)

24 Number of directly billed ICPs 1 (at year end)



27

28 Maximum monthly amount of gas entering network (GJ/month) 1,277,932



30 June 2014

Auckland



Residential

Commercial

37 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S9d.Demand Auckland


Company Name

For Year Ended


SCHEDULE 10a: REPORT ON NETWORK RELIABILITY AND INTERRUPTIONS

sch ref

8 10a(i): Interruptions

9 Interruptions by class Actual

10 Class A (planned interruptions by GTB) -

11 Class B (planned interruptions on the network) 1,529

12 Class C (unplanned interruptions on the network) 111

13 Class D (unplanned interruptions by GTB) -

14 Class I (unplanned interruptions caused by third party damage) 435

15 Total 2,075

16 Number of unplanned outage events (interruptions that affect more than 5 ICPs) Actual

17 Vector Region 10

18

19

20

21

22 Actual

23 Vector Region 7

24

25

26

27

28 10a(ii): Reliability

29 Overall reliability SAIDI SAIFI CAIDI

30 Based on the total number of interruptions 4,700 21.6 218

31 Class I (unplanned interruptions caused by third party damage) 2,100 7.30 288

32 Class B (planned interruptions on the network) SAIDI SAIFI CAIDI

33 Vector Region 2,460 13.4 184

34 -

35 -

36 -

37 -

38 Class C (unplanned interruptions on the network) SAIDI SAIFI CAIDI

39 Vector Region 98.3 0.985 100

40 -

41 -

42 -

43 -


30 June 2014

Combined

This schedule requires a summary of the key measures of network reliability (interruptions, SAIDI, SAIFI and CAIDI) for the disclosure year

GDBs must provide explanatory comment on their network reliability for the disclosure year in Schedule 14 (Explanatory Notes to Templates). The SAIDI and SAIFI information is part of audited

disclosure information (as defined in section 1.4 of the ID determination), and so is subject to the assurance report required by section 2.8.

Number of unplanned outage events caused by third party damage (interruptions that affect more than 5 ICPs)

38 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S10a.Reliability combined


Company Name

For Year Ended



sch ref




11 Class B (planned interruptions on the network) 873




15 Total 1,133


17 North Island Regions 5

18

19

20

21

22 Actual


24

25

26

27




31 Class I (unplanned interruptions caused by third party damage) 4,400 12.7 346


33 North Island Regions 2,430 16.4 148

34 -

35 -

36 -

37 -


39 North Island Regions 176 1.55 114

40 -

41 -

42 -

43 -


30 June 2014

North Island





39 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S10a.Reliability North Island


Company Name

For Year Ended



sch ref




11 Class B (planned interruptions on the network) 656




15 Total 942


17 Auckland Region 5

18

19

20

21

22 Actual


24

25

26

27




31 Class I (unplanned interruptions caused by third party damage) 620 3.59 173


33 Auckland Region 2,470 11.2 221

34 -

35 -

36 -

37 -


39 Auckland Region 44.6 0.597 75

40 -

41 -

42 -

43 -


30 June 2014

Auckland





40 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S10a.Reliability Auckland


Company Name

For Year Ended


SCHEDULE 10b: REPORT ON NETWORK INTEGRITY AND CONSUMER SERVICE

sch ref

8 10b(i): System Condition and Integrity

9 Number of confirmed public reported gas escapes / total length of pipeline (escapes/1000 km) Actual

10 Vector Region 46.0

11

12

13

14

15 Number of leaks detected by routine survey / total length of pipeline (leaks/1000 km) Actual


17

18

19

20

21 Number of third party damage events / total length of pipeline (events/1000 km) Actual


23

24

25

26

27 Number of poor pressure events due to network causes Actual

28 Vector Region 6

29

30

31

3233

34 Number of telephone calls to emergency numbers answered within 30 seconds / total number of calls Actual

35 Vector Region 91.67%

36

37

38

39

40 Product control—safety of distribution gas Actual

41 Number of non-compliant odour tests 5

42 10b(ii): Consumer Service

43 Response time to emergencies (RTE)

Proportion of

emergencies

responded to

within 1 hour (%)

Proportion of

emergencies

responded to

within 3 hours (%)

Average call

response time

(hours)

Number of

emergencies

44 Vector Region 91.2% 100.0% 0.6 182

45

46

47

48

49 Number of complaints Actual

50 Number of complaints per average total consumer numbers 0.0018


30 June 2014

This schedule requires a summary of the key measures of network Integrity (gas escapes, response time to emergencies etc) for the disclosure year.

Combined

41 GDB Information Disclosure 2014 schedules 1 - 10 (public).xlsx S10b.Integrity_combined

Company Name

For Year Ended



sch ref



10 North Island Regions 52.1

11

12

13

14



17

18

19

20



23

24

25

26



29

30

31

3233


35 North Island Regions 91.67%

36

37

38

39





Proportion of

emergencies

responded to

within 1 hour (%)

Proportion of

emergencies

responded to

within 3 hours (%)

Average call

response time

(hours)

Number of

emergencies

44 North Island Regions 86.4% 100.0% 0.6 66

45

46

47

48




30 June 2014

North Island Network


Company Name

For Year Ended



sch ref



10 Auckland Region 40.8

11

12

13

14



17

18

19

20



23

24

25

26



29

30

31

3233


35 Auckland Region 91.67%

36

37

38

39





Proportion of

emergencies

responded to

within 1 hour (%)

Proportion of

emergencies

responded to

within 3 hours (%)

Average call

response time

(hours)

Number of

emergencies

44 Auckland Region 94.0% 100.0% 0.6 116

45

46

47

48




30 June 2014

Auckland Network


GDB Information Disclosure Requirements Information ... · commissioned and asset disposals should...

Documents

Transcript of GDB Information Disclosure Requirements Information ... · commissioned and asset disposals should...